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Abstract:

A tubular component includes a limit collar disposed about the tubular
component, and the limit collar comprises a body portion comprising a
plurality of upsets disposed on an inner surface of the body portion,
wherein the plurality of upsets define a first ring, a second ring, and
at least one rib, at least one chamber formed between the inner surface
of the body portion, an outer surface of the tubular component, and one
or more surfaces of the first ring, the second ring, or the at least one
rib, and a binder portion disposed in the at least one chamber.

Claims:

1. A tubular component comprising: a limit collar disposed about the
tubular component, wherein the limit collar comprises: a body portion
comprising a plurality of upsets disposed on an inner surface of the body
portion, wherein the plurality of upsets define a first ring, a second
ring, and at least one rib; at least one chamber formed between the inner
surface of the body portion, an outer surface of the tubular component,
and one or more surfaces of the first ring, the second ring, or the at
least one rib; and a binder portion disposed in the at least one chamber.

2. The tubular component of claim 1, wherein the binder portion engages
the body portion and the tubular component.

3. The tubular component of claim 1, wherein the body portion further
comprises one or more holes.

4. The tubular component of claim 3, wherein the body portion further
comprises a set screw that engages the tubular component disposed within
one of the one or more holes.

5. The tubular component of claim 1, wherein the rib comprises one or
more channels.

6. The tubular component of claim 1, wherein the plurality of upsets
further define a plurality of ribs.

7. The tubular component of claim 1, wherein an edge adjacent an end of
the body portion is tapered.

8. A method comprising: providing a limit collar disposed on a wellbore
tubular and a first component slidingly engaged on the wellbore tubular,
wherein the limit collar comprises: a body portion comprising a plurality
of recesses disposed on an inner surface of the body portion, wherein the
plurality of recesses define a first ring, a second ring, and at least
one rib; at least one chamber formed between a recess of the plurality of
recesses, an outer surface of the wellbore tubular, and one or more
surfaces of the first ring, the second ring, or the at least one rib; and
a binder portion disposed in the at least one chamber; and conveying the
wellbore tubular within a wellbore, wherein the first component is
retained on the wellbore tubular due to the engagement of the first
component with the limit collar.

9. The method of claim 8, wherein the limit collar is comprised of
non-metallic materials.

10. The method of claim 8, wherein the body portion or the binder portion
comprise a composite material.

12. The method of claim 11, wherein the matrix material comprises a resin
selected from the group consisting of: a thermosetting resin, a
thermoplastic resin, an orthophthalic polyester, an isophthalic
polyester, a phthalic/maelic type polyester, a vinyl ester, a
thermosetting epoxy, a phenolic component, a cyanate component, a
bismaleimide component, a nadic end-capped polyimide, a polysulfone, a
polyamide, a polycarbonate, a polyphenylene oxide, a polysulfide, a
polyether ether ketone, a polyether sulfone, a polyamide-imide, a
polyetherimide, a polyimide, a polyacrylate, a liquid crystalline
polyester, a polyurethane, a polyurea, and any combination thereof.

13. The method of claim 11, wherein the matrix material comprises a two
component resin comprising a hardenable resin selected from group
consisting of: an organic resin, a bisphenol A diglycidyl ether resin, a
butoxymethyl butyl glycidyl ether resin, a bisphenol A-epichlorohydrin
resin, a bisphenol F resin, a polyepoxide resin, a novolak resin, a
polyester resin, a phenol-aldehyde resin, a urea-aldehyde resin, a furan
resin, a urethane resin, a glycidyl ether resin, an epoxide resin, and
any combination thereof.

15. The method of claim 10, wherein the composite material comprises a
fiber selected from the group consisting of: a glass fiber, an e-glass
fiber, an A-glass fiber, an E-CR-glass fiber, a C-glass fiber, a D-glass
fiber, an R-glass fiber, an S-glass fiber, a cellulosic fiber, a carbon
fiber, a graphite fiber, a ceramic fibers, an aramid fiber, and any
combination thereof.

17. A method comprising: providing a wellbore tubular; providing a body
portion comprising a plurality of upsets disposed on an inner surface of
the body portion, wherein the plurality of upsets define a first ring, a
second ring, and at least one rib; disposing the body portion about the
wellbore tubular, wherein at least one chamber is formed between the
inner surface of the body portion, an outer surface of the wellbore
tubular, and one or more surfaces of the first ring, the second ring, or
the at least one rib; and introducing a binder portion material into the
at least one chamber.

18. The method of claim 17, wherein disposing the body portion about the
wellbore tubular comprises: disposing a set screw in a hole disposed in
the body portion; and engaging the set screw with the wellbore tubular.

19. The method of claim 17, further comprising treating the outer surface
of the wellbore tubular to provide a surface for bonding to the binder
portion prior to disposing the body portion about the wellbore tubular.

20. The method of claim 17, wherein the binder portion material is
introduced into the at least one chamber through one or more holes
disposed in the body portion.

21. The method of claim 20, further comprising disposing a set screw in a
hole of the one or more holes into which the binder portion material is
introduced after the binder portion has been introduced into the at least
one chamber.

Description:

CROSS-REFERENCE TO RELATED APPLICATIONS

[0001] None.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

[0002] Not applicable.

REFERENCE TO A MICROFICHE APPENDIX

[0003] Not applicable.

BACKGROUND

[0004] Wellbores are sometimes drilled into subterranean formations that
contain hydrocarbons to allow recovery of the hydrocarbons. Some wellbore
servicing methods employ wellbore tubulars that are lowered into the
wellbore for various purposes throughout the life of the wellbore.
Various components can be disposed on the outer surface of a wellbore
tubular to achieve a variety of effects during drilling, completion, and
servicing operations. For example, centralizers can be used to maintain
the wellbore tubulars aligned within the wellbore since wellbores are not
generally perfectly vertical. Alignment may help prevent any friction
between the wellbore tubular and the side of the wellbore wall or casing,
potentially reducing any damage that may occur. Common components
disposed about a wellbore tubular use limit collars, which are also
referred to as stop collars or limit clamps, located at either end of the
components to maintain the positioning of the component relative to the
wellbore tubular as the tubular is conveyed into and out of the wellbore.
The various components may be free to move within the limits of the limit
collars. Traditional limit collars use one or more set screws passing
through a metal stop collar and contacting the wellbore tubular to couple
the stop collar to the tubular.

SUMMARY

[0005] In an embodiment, a tubular component includes a limit collar
disposed about the tubular component, and the limit collar comprises a
body portion comprising a plurality of upsets disposed on an inner
surface of the body portion, wherein the plurality of upsets define a
first ring, a second ring, and at least one rib, at least one chamber
formed between the inner surface of the body portion, an outer surface of
the tubular component, and one or more surfaces of the first ring, the
second ring, or the at least one rib, and a binder portion disposed in
the at least one chamber. The binder portion may engage the body portion
and the tubular component. The body portion further may also include one
or more holes, and a set screw that engages the tubular component may be
disposed within one of the one or more holes. The rib may comprise one or
more channels, and the plurality of upsets may further define a plurality
of ribs. An edge adjacent an end of the body portion may be tapered.

[0006] In an embodiment, a method comprises providing a limit collar
disposed on a wellbore tubular and a first component slidingly engaged on
the wellbore tubular, wherein the limit collar comprises: a body portion
comprising a plurality of recesses disposed on an inner surface of the
body portion, wherein the plurality of recesses define a first ring, a
second ring, and at least one rib; at least one chamber formed between a
recess of the plurality of recesses, an outer surface of the wellbore
tubular, and one or more surfaces of the first ring, the second ring, or
the at least one rib; and a binder portion disposed in the at least one
chamber; and conveying the wellbore tubular within a wellbore, wherein
the first component is retained on the wellbore tubular due to the
engagement of the first component with the limit collar. The limit collar
may be comprised of non-metallic materials. The body portion or the
binder portion may comprise a composite material, and the composite
material comprises a matrix material. The matrix material may comprise a
resin selected from the group consisting of: a thermosetting resin, a
thermoplastic resin, an orthophthalic polyester, an isophthalic
polyester, a phthalic/maelic type polyester, a vinyl ester, a
thermosetting epoxy, a phenolic component, a cyanate component, a
bismaleimide component, a nadic end-capped polyimide, a polysulfone, a
polyamide, a polycarbonate, a polyphenylene oxide, a polysulfide, a
polyether ether ketone, a polyether sulfone, a polyamide-imide, a
polyetherimide, a polyimide, a polyacrylate, a liquid crystalline
polyester, a polyurethane, a polyurea, and any combination thereof. The
matrix material may comprise a two component resin comprising a
hardenable resin selected from group consisting of: an organic resin, a
bisphenol A diglycidyl ether resin, a butoxymethyl butyl glycidyl ether
resin, a bisphenol A-epichlorohydrin resin, a bisphenol F resin, a
polyepoxide resin, a novolak resin, a polyester resin, a phenol-aldehyde
resin, a urea-aldehyde resin, a furan resin, a urethane resin, a glycidyl
ether resin, an epoxide resin, and any combination thereof. The matrix
material may comprise a two component resin comprising a hardening agent
selected from group consisting of: a cyclo-aliphatic amine; an aromatic
amine; an aliphatic amine; imidazole; pyrazole; pyrazine; pyrimidine;
pyridazine; 1H-indazole; purine; phthalazine; naphthyridine; quinoxaline;
quinazoline; phenazine; imidazolidine; cinnoline; imidazoline;
1,3,5-triazine; thiazole; pteridine; an indazole; an amine; a polyamine;
an amide; a polyamide; 2-ethyl-4-methyl imidazole; and any combination
thereof. The composite material may comprise a fiber selected from the
group consisting of: a glass fiber, an e-glass fiber, an A-glass fiber,
an E-CR-glass fiber, a C-glass fiber, a D-glass fiber, an R-glass fiber,
an S-glass fiber, a cellulosic fiber, a carbon fiber, a graphite fiber, a
ceramic fibers, an aramid fiber, and any combination thereof. The binder
portion may comprise a curable resin and ceramic particulate filler
material.

[0007] In an embodiment, a method comprises providing a wellbore tubular;
providing a body portion comprising a plurality of upsets disposed on an
inner surface of the body portion, wherein the plurality of upsets define
a first ring, a second ring, and at least one rib; disposing the body
portion about the wellbore tubular, wherein at least one chamber is
formed between the inner surface of the body portion, an outer surface of
the wellbore tubular, and one or more surfaces of the first ring, the
second ring, or the at least one rib; and introducing a binder portion
material into the at least one chamber. Disposing the body portion about
the wellbore tubular may include disposing a set screw in a hole disposed
in the body portion; and engaging the set screw with the wellbore
tubular. The method may also include treating the outer surface of the
wellbore tubular to provide a surface for bonding to the binder portion
prior to disposing the body portion about the wellbore tubular. The
binder portion material may be introduced into the at least one chamber
through one or more holes disposed in the body portion. The method may
also include disposing a set screw in a hole of the one or more holes
into which the binder portion material is introduced after the binder
portion has been introduced into the at least one chamber.

[0008] These and other features will be more clearly understood from the
following detailed description taken in conjunction with the accompanying
drawings and claims.

BRIEF DESCRIPTION OF THE DRAWINGS

[0009] For a more complete understanding of the present disclosure and the
advantages thereof, reference is now made to the following brief
description, taken in connection with the accompanying drawings and
detailed description:

[0010] FIG. 1 is a cut-away view of an embodiment of a wellbore servicing
system according to an embodiment;

[0011] FIG. 2A is a cross-sectional view of a limit collar according to an
embodiment;

[0012] FIG. 2B is a isometric view of a limit collar according to an
embodiment;

[0013] FIG. 3 is another cross-sectional view of a limit collar according
to an embodiment;

[0014] FIG. 4 is still another cross-sectional view of a limit collar
according to an embodiment.

DETAILED DESCRIPTION OF THE EMBODIMENTS

[0015] In the drawings and description that follow, like parts are
typically marked throughout the specification and drawings with the same
reference numerals, respectively. The drawing figures are not necessarily
to scale. Certain features of the invention may be shown exaggerated in
scale or in somewhat schematic form and some details of conventional
elements may not be shown in the interest of clarity and conciseness.

[0016] Unless otherwise specified, any use of any form of the terms
"connect," "engage," "couple," "attach," or any other term describing an
interaction between elements is not meant to limit the interaction to
direct interaction between the elements and may also include indirect
interaction between the elements described. In the following discussion
and in the claims, the terms "including" and "comprising" are used in an
open-ended fashion, and thus should be interpreted to mean "including,
but not limited to . . . ". Reference to up or down will be made for
purposes of description with "up," "upper," or "upward" meaning toward
the surface of the wellbore and with "down," "lower," or "downward"
meaning toward the terminal end of the well, regardless of the wellbore
orientation. Reference to in or out will be made for purposes of
description with "in," "inner," or "inward" meaning toward the center of
the wellbore in a radial direction (i.e., towards the central axis of the
wellbore and/or the limit collar) and with "out," "outer," or "outward"
meaning towards the wall of the well in a radial direction, regardless of
the wellbore orientation. The various characteristics mentioned above, as
well as other features and characteristics described in more detail
below, will be readily apparent to those skilled in the art with the aid
of this disclosure upon reading the following detailed description of the
embodiments, and by referring to the accompanying drawings.

[0017] Referring to FIG. 1, an example of a wellbore operating environment
is shown. As depicted, the operating environment comprises a drilling rig
106 that is positioned on the earth's surface 104 and extends over and
around a wellbore 112 that penetrates a subterranean formation 102 for
the purpose of recovering hydrocarbons. The wellbore 114 may be drilled
into the subterranean formation 102 using any suitable drilling
technique. The wellbore 114 extends substantially vertically away from
the earth's surface 104 over a vertical wellbore portion 116, deviates
from vertical relative to the earth's surface 104 over a deviated
wellbore portion 136, and transitions to a horizontal wellbore portion
118. In alternative operating environments, all or portions of a wellbore
may be vertical, deviated at any suitable angle, horizontal, and/or
curved. The wellbore may be a new wellbore, an existing wellbore, a
straight wellbore, an extended reach wellbore, a sidetracked wellbore, a
multi-lateral wellbore, and other types of wellbores for drilling and
completing one or more production zones. Further the wellbore may be used
for both producing wells and injection wells.

[0018] A wellbore tubular string 120 comprising a limit collar 200 may be
lowered into the subterranean formation 102 for a variety of workover or
treatment procedures throughout the life of the wellbore. The embodiment
shown in FIG. 1 illustrates the wellbore tubular 120 in the form of a
casing string being lowered into the subterranean formation with the
limit collar retaining a centralizer 122. It should be understood that
the wellbore tubular 120 comprising a limit collar 200 is equally
applicable to any type of wellbore tubular being inserted into a
wellbore, including as non-limiting examples drill pipe, production
tubing, rod strings, and coiled tubing. The limit collar 200 may also be
used to retain one or more components on various other tubular devices,
cylindrical components, and/or downhole tools (e.g., various downhole
subs and workover tools). In the embodiment shown in FIG. 1, the wellbore
tubular 120 comprising the limit collar 200 is conveyed into the
subterranean formation 102 in a conventional manner and may subsequently
be secured within the wellbore 114 by filling an annulus 112 between the
wellbore tubular 120 and the wellbore 114 with cement.

[0019] The drilling rig 106 comprises a derrick 108 with a rig floor 110
through which the wellbore tubular 120 extends downward from the drilling
rig 106 into the wellbore 114. The drilling rig 106 comprises a motor
driven winch and other associated equipment for extending the casing
string 120 into the wellbore 114 to position the wellbore tubular 120 at
a selected depth. While the operating environment depicted in FIG. 1
refers to a stationary drilling rig 106 for lowering and setting the
wellbore tubular 120 comprising the limit collar 200 within a land-based
wellbore 114, in alternative embodiments, mobile workover rigs, wellbore
servicing units (such as coiled tubing units), and the like may be used
to lower the wellbore tubular 120 comprising the limit collar 200 into a
wellbore. It should be understood that a wellbore tubular 120 comprising
the limit collar 200 may alternatively be used in other operational
environments, such as within an offshore wellbore operational
environment.

[0020] In alternative operating environments, a vertical, deviated, or
horizontal wellbore portion may be cased and cemented and/or portions of
the wellbore may be uncased. For example, uncased section 140 may
comprise a section of the wellbore 114 ready for being cased with
wellbore tubular 120. In an embodiment, a limit collar 200 may be used on
production tubing in a cased or uncased wellbore. In an embodiment, a
portion of the wellbore 114 may comprise an underreamed section. As used
herein, underreaming refers to the enlargement of an existing wellbore
below an existing section, which may be cased in some embodiments. An
underreamed section may have a larger diameter than a section upward from
the underreamed section. Thus, a wellbore tubular passing down through
the wellbore may pass through a smaller diameter passage followed by a
larger diameter passage.

[0021] Regardless of the type of operational environment in which the
limit collar 200 is used, it will be appreciated that the limit collar
200 serves to limit the longitudinal movement and/or retain one or more
components disposed about a wellbore tubular. In an embodiment, a
plurality of limit collars 200 may be used to limit and/or retain one or
more components about a wellbore tubular. As described in greater detail
below with respect to FIG. 2A and FIG. 2B, the limit collar 200 comprises
a body portion 202 and a binder portion 203 disposed between the body
portion 202 and the wellbore tubular 220. In an embodiment, the limit
collar 200 described herein may be used to retain one or more components
226 on the wellbore tubular 220. In an embodiment, the limit collar 200
may be formed from non-metallic and/or a composite materials and may be
used to prevent corrosion on a metallic wellbore tubular.

[0022] Referring now to FIG. 2A and FIG. 2B, an embodiment of the limit
collar 200 disposed on a wellbore tubular 220 is shown in cross-section
and as an isometric view, respectively. As described above, the limit
collar 200 comprises a body portion 202 that comprises a plurality of
rings 204, 206, one or more ribs 208, and one or more holes 210. In an
embodiment, the body portion 202 comprises a first ring 204, a second
ring 206, and a rib 208. The body portion 202 may comprise a generally
cylindrical member having a flowbore disposed therethrough. The flowbore
may be sized to be disposed about the outer diameter of a wellbore
tubular 220. The outer diameter of the body portion 202 may be generally
uniform along the outer surface of the body portion 202 in a longitudinal
direction (i.e., a direction parallel to the central longitudinal axis of
the limit collar 200 and wellbore tubular 220), though one or both ends
may be tapered as described in more detail herein. One or more inner
upsets (e.g., first ring 204, second ring 206, and/or rib 208) having an
inner diameter less than the inner diameter of one or more recess
portions 216 and having a radial height 212 may be disposed along the
inner diameter of the body portion 202. A first ring 204 may be formed by
one such inner upset disposed at a first end of the body portion 202. The
first ring 204 may have an inner diameter chosen to allow the collar 200
to slidingly engage the wellbore tubular 220 while still maintaining
contact with the outer surface of the wellbore tubular 220. In an
embodiment, a small gap may exist between the inner diameter of the first
ring 204 and the outer diameter of the wellbore tubular 220. In an
embodiment, a layer of material may be disposed between the inner
diameter of the first ring 204 and the outer diameter of the wellbore
tubular 220 to substantially prevent fluid flow through the small gap. In
an embodiment, the end 222 of the body portion 202 adjacent the first
ring 204 may generally have a flat surface orientated normal to the outer
surface of the wellbore tubular 220. This configuration may allow for
uniform contact with the one or more components 226 retained on the
wellbore tubular 220. In an embodiment, the end 222 may have a different
configuration and/or orientation. The first ring 204 may be disposed
about the interior surface of the body portion 202 to form a continuous
ring around the entire inner surface of the body portion 202.

[0023] A second ring 206 may be formed by another such inner upset
disposed at a second end of the body portion 202. The second ring 206 may
have an inner diameter chosen to allow the collar 200 to slidingly engage
the wellbore tubular 220 while still maintaining contact with the outer
surface of the wellbore tubular 220. In an embodiment, a small gap may
exist between the inner diameter of the second ring 206 and the outer
diameter of the wellbore tubular 220. In an embodiment, a layer of
material may be disposed between the inner diameter of the second ring
206 and the outer diameter of the wellbore tubular 220 to substantially
prevent fluid flow through the small gap. In an embodiment, the edge 224
of the body portion 202 may be tapered or angled with respect to the
surface of the wellbore tubular 220 to aid in movement of the limit
collar 200 through the wellbore. In an embodiment, tapered or angled edge
224 is a leading edge in a direction of travel of the wellbore tubular
220 within the wellbore (e.g., a downhole leading edge as the wellbore
tubular is being run into a wellbore). In an embodiment, tapered or
angled edge 224 is the edge of the body portion 202 not in contact with
the one or more components 226 retained on the wellbore tubular 220. The
second ring 206 may be disposed about the interior surface of the body
portion 202 to form a continuous ring around the entire inner surface of
the body portion 202.

[0024] The body portion 202 may comprise one or more ribs 208 formed by
one or more upsets disposed on the interior surface of the body portion
202. In an embodiment as shown in FIG. 2A and FIG. 2B, the body portion
may comprise one rib 208. The rib 208 may have an inner diameter chosen
to allow the collar 200 to slidingly engage the wellbore tubular 220
while still maintaining contact with the outer surface of the wellbore
tubular 220. In an embodiment, a small gap may exist between the inner
diameter of the rib 208 and the outer diameter of the wellbore tubular
220. In some embodiments, the rib 208 may have an inner diameter that
does not engage the wellbore tubular 220, but rather leaves a gap between
the interior surface of the rib 208 and the outer surface of the wellbore
tubular 220. The rib 208 may be disposed about the interior surface of
the body portion 202 to form a continuous ring around the entire inner
surface of the body portion 202.

[0025] In an embodiment, the rib 208 may comprise one or more channels 214
disposed along the length of the rib 208. The channels 214 may comprise a
recess disposed in the rib to provide a fluid communication pathway
between the chambers 230, 232 formed by the one or more recesses 216, the
outer surface of the wellbore tubular 220, and one or more edges of the
corresponding inner upsets (e.g., first ring 204, second ring 206, and/or
rib 208). The channel 214 may be formed along the inner surface of the
body portion 202 through the rib 208 and may have a diameter generally
equivalent to that of the recess 216. In an embodiment, the diameter of
the channel 214 may be less than that of the recess 216 but greater than
that of the rib 208. In an embodiment, the rib 208 may comprise 1 to
about 20 channels, alternatively 2 to about 10 channels, or alternatively
2 to about 8 channels. When a plurality of channels 214 is present in a
rib 208, the channels may be uniformly distributed along the
circumference of the rib 208, or the channels may be non-uniformly
distributed along the circumference of the rib 208.

[0026] The limit collar 200 may also have one or more holes 210 disposed
through the body portion 202. The holes 210 may generally be cylindrical
in shape and may pass through the first ring 204, the second ring 206,
the rib 208, and/or the body portion adjacent the recesses 216. The holes
210 may be disposed in a generally radial direction to allow a set screw
to engage the wellbore tubular 220 at an approximately normal angle. The
interior surface of the holes 210 may be generally smooth, or in some
embodiments, may be threaded to receive a set screw. In an embodiment,
one or more holes 210 may be configured to receive a fluid connection for
use in disposing the limit collar 200 on the wellbore tubular 220. When a
hole 210 is disposed in a rib 208, the hole may be aligned with the
channel 214 so that fluid communication is provided between the hole 210
and the channel 214. The set screws may be of any type known in the art.
In an embodiment, the set screw is a non-metallic set screw, and the set
screw may comprise a composite material of the same or similar type used
to form the body portion 202, as described in more detail herein.

[0027] In an embodiment, the body portion 202 of the limit collar 200 may
have a plurality of particulates disposed on the outer surface of the
body portion 202. For example, the areas of the body portion 202
anticipated to contact a surface of a wellbore and/or tubular into which
the wellbore tubular 220 comprising the limit collar 200 is placed may
comprise one or more particulates to limit the effects of abrasion and/or
erosion. The particulates may be disposed along the entire length of the
outer surface of the limit collar 200 or only those portions anticipated
to contact the wellbore wall during conveyance of the wellbore tubular
220 within the wellbore such as a tapered edge 224 of the end adjacent
the second ring 206. As used herein, disposed on the outer surface
generally refers to the particulates being located at the outer surface
of the body portion 202 and may include the particulates being embedded
in the outer surface, deposited in, on the outer surface, and/or coated
on the outer surface. The particulates may generally be resistant to
erosion and/or abrasion to prevent wear on the points of contact between
the body portion 202 surfaces and the wellbore walls or inner surfaces of
the wellbore. The shape, size, and composition of the particulates may be
selected to affect the amount of friction between the limit collar 200
and the wellbore walls during conveyance of the wellbore tubular 220
comprising the limit collar 200 within the wellbore. In an embodiment,
the particulates may comprise a low surface energy and or coefficient of
friction, and/or may comprise substantially spherical particles. The
particulates may have a distribution of sizes, or they may all be
approximately the same size. In an embodiment, the particulates may be
within a distribution of sizes ranging from about 0.001 inches to about
0.2 inches, 0.005 inches to about 0.1 inches, 0.01 inches to about 0.005
inches. In an embodiment, the particulates may be about 0.02 inches to
about 0.004 inches. The particulates may comprise any material capable of
resisting abrasion and erosion when disposed on a limit collar 200 and
contacted with the wellbore wall. In an embodiment, the particulates may
be formed from metal and/or ceramic. For example, the particulates may
comprise zirconium oxide. In an embodiment, the particulates may be
coated with any of the surface coating agents discussed below to aid in
bonding between the particulates and one or more materials of
construction of the limit collar 200 or any limit collar 200 components
(e.g., the body portion 202 and/or the binder portion 203).

[0028] The body portion 202 and/or one or more set screws may be formed
from one or more composite materials. A composite material comprises a
heterogeneous combination of two or more components that differ in form
or composition on a macroscopic scale. While the composite material may
exhibit characteristics that neither component possesses alone, the
components retain their unique physical and chemical identities within
the composite. Composite materials may include a reinforcing agent and a
matrix material. In a fiber-based composite, fibers may act as the
reinforcing agent. The matrix material may act to keep the fibers in a
desired location and orientation and also serve as a load-transfer medium
between fibers within the composite.

[0030] In an embodiment, the matrix material may comprise a two-component
resin composition. Suitable two-component resin materials may include a
hardenable resin and a hardening agent that, when combined, react to form
a cured resin matrix material. Suitable hardenable resins that may be
used include, but are not limited to, organic resins such as bisphenol A
diglycidyl ether resins, butoxymethyl butyl glycidyl ether resins,
bisphenol A-epichlorohydrin resins, bisphenol F resins, polyepoxide
resins, novolak resins, polyester resins, phenol-aldehyde resins,
urea-aldehyde resins, furan resins, urethane resins, glycidyl ether
resins, other epoxide resins, and any combinations thereof. Suitable
hardening agents that can be used include, but are not limited to,
cyclo-aliphatic amines; aromatic amines; aliphatic amines; imidazole;
pyrazole; pyrazine; pyrimidine; pyridazine; 1H-indazole; purine;
phthalazine; naphthyridine; quinoxaline; quinazoline; phenazine;
imidazolidine; cinnoline; imidazoline; 1,3,5-triazine; thiazole;
pteridine; indazole; amines; polyamines; amides; polyamides;
2-ethyl-4-methyl imidazole; and any combinations thereof. In an
embodiment, one or more additional components may be added the matrix
material to affect the properties of the matrix material. For example,
one or more elastomeric components (e.g., nitrile rubber) may be added to
increase the flexibility of the resulting matrix material.

[0031] The fibers may lend their characteristic properties, including
their strength-related properties, to the composite. Fibers useful in the
composite materials used to form the body portion 202 may include, but
are not limited to, glass fibers (e.g., e-glass, A-glass, E-CR-glass,
C-glass, D-glass, R-glass, and/or S-glass), cellulosic fibers (e.g.,
viscose rayon, cotton, etc.), carbon fibers, graphite fibers, metal
fibers (e.g., steel, aluminum, etc.), ceramic fibers, metallic-ceramic
fibers, aramid fibers, and any combinations thereof. In an embodiment,
only non-metallic fibers may be used. Additional components that may be
used with the fibers or in place of the fibers may include particulates
and/or chopped fibers comprising ceramic, polymer, metals, oxides, or
other suitable composite materials including any of the materials
described with respect to the fibers but in particulate and/or chopped
fiber form.

[0032] The strength of the interface between the fibers and the matrix
material may be modified or enhanced through the use of a surface coating
agent. The surface coating agent may provide a physico-chemical link
between the fiber and the resin matrix material, and thus may have an
impact on the mechanical and chemical properties of the final composite.
The surface coating agent may be applied to fibers during their
manufacture or any other time prior to the formation of the composite
material. Suitable surface coating agents may include, but are not
limited to, surfactants, anti-static agents, lubricants, silazane,
siloxanes, alkoxysilanes, aminosilanes, silanes, silanols, polyvinyl
alcohol, and any combinations thereof.

[0033] The body portion 202 comprising a composite material may be formed
using any techniques known for forming a composite material into a
desired shape. The fibers used in the process may be supplied in any of a
number of available forms. For example, the fibers may be supplied as
individual filaments wound on bobbins, yarns comprising a plurality of
fibers wound together, tows, rovings, tapes, fabrics, other fiber
broadgoods, or any combinations thereof. The fiber may pass through any
number rollers, tensioners, or other standard elements to aid in guiding
the fiber through the process to a resin bath.

[0034] In an embodiment, a fiber may first be delivered to a resin bath.
The resin may comprise any of those resins or combination of resins known
in the art, including those listed herein. The resin bath can be
implemented in a variety of ways. For example, the resin bath may
comprise a doctor blade roller bath wherein a polished rotating cylinder
that is disposed in the bath picks up resin as it turns. The doctor bar
presses against the cylinder to obtain a precise resin film thickness on
cylinder and pushes excess resin back into the bath. As the fiber passes
over the top of the cylinder and is in contact with the cylinder, the
fiber may contact the resin film and wet out. In another embodiment,
resin bath may comprise an immersion bath where the fiber is partially or
wholly submerged into the resin and then pulled through a set of wipers
or roller that remove excess resin.

[0035] After leaving the resin bath, the resin-wetted fiber may pass
through various rings, eyelets, and/or combs to direct the resin-wetted
fiber to a mold to form the body portion 202. In an embodiment, the mold
may comprise a generally cylindrical mandrel having one or more features
to cause the formation of the recesses 216. In another embodiment, the
mold may comprise a cylindrical mandrel with a generally smooth surface
and the recesses 216 may be formed after the body portion has been
allowed to harden and/or set. The mold upon which the resin-wetted fibers
are wound may have a diameter approximately the same as the diameter of a
wellbore tubular upon which the final limit collar 200 is to be disposed.
The fibers may be wound onto the mold to form the body portion 202 using
an automated process that may allow for control of the direction of the
winding and the winding pattern. The winding process may determine the
thickness profile of the body portion 202 in the formation process. In an
embodiment, particulates, which may comprise a surface coating agent, may
be disposed on the outer surface of the body portion after the fibers
leave the resin bath and/or when disposed on the mold.

[0036] The wound fibers may be allowed to harden, cure, and/or set to a
desired degree on the mold. In an embodiment, the particulates, which may
comprise a surface coating agent, may be disposed on the outer surface of
the body portion. The mold may then be heated to heat cure the resin to a
final, cured state. In another embodiment, other curing techniques may be
used to cause the body portion to harden to a final, cured state. After
completing the curing process, the mold may be disassembled and the body
portion removed. In an embodiment, the body portion may be removed from
the mold by pressing the cylindrical mandrel out of the body portion. In
an embodiment in which the cylindrical mandrel has a generally smooth
surface, the recesses may be milled, cut, or otherwise formed on the
inner surface of the body portion after the body portion is removed from
the cylindrical mandrel. The limit collar may then be formed by disposing
the body portion on the wellbore tubular and introducing the binder
portion 203 as described in more detail herein.

[0037] The winding process used to form the body portion 202 may determine
the direction of the fibers and the thickness of the rings 204, 206, the
recess portions 216, and/or the one or more ribs 208. The ability to
control the direction and pattern of winding may allow for the properties
of the completed limit collar 200 to possess direction properties. In an
embodiment, the fibers in the body portion 202 may generally be aligned
in a circumferential direction, though various cross winding patterns may
also be useful.

[0038] In an embodiment, the body portion 202 formation process may be
designed by and/or controlled by an automated process, which may be
implemented as software operating on a processor as part of a computer
system. The automated process may consider various desired properties of
the limit collar as inputs and calculate a design of the limit collar
based on the properties of the available materials and the available
manufacturing processes. In an embodiment, the automated process may
consider various properties of the materials available for use in the
construction of the limit collar including, but not limited to, the
diameter, stiffness, moduli, and cost of the fibers. The use of the
automated process may allow for limit collars to be designed for specific
uses and allow the most cost effective design to be chosen at the time of
manufacture. Thus, the ability to tailor the design of the limit collar
to provide a desired set of properties may offer an advantage of the
limit collar and methods disclosed herein. In an embodiment, the body
portion 202 may be manufactured at a location separated from the wellbore
tubular and/or the wellbore, and installed at the wellbore through the
introduction of the binder portion into the body portion.

[0039] In an embodiment, one or more set screws may be prepared using a
similar process to that used to form the body portion. For example, a
sheet of composite material may be formed, and one or more set screws may
be cut, milled, or otherwise shaped from the material. Alternatively, the
set screws may be individually formed from a non-metallic material,
resin, and/or a composite material. One or more threads may be machined
into and/or integrally formed (e.g., through the use of a mold comprising
the corresponding thread pattern) with the set screw.

[0040] The binder portion 203 can comprise any material that engages,
couples, and/or bonds to the wellbore tubular 2220 and/or the body
portion 202 via the formation of a chemical and/or mechanical bond to
retain the body portion 202 in position relative to the wellbore tubular
220. The binder portion 203 may be disposed within the chambers 230, 232
formed by the one or more recesses 216, the outer surface of the wellbore
tubular 220, and one or more edges of the corresponding inner upsets
(e.g., first ring 204, second ring 206, and/or rib 208). The binder
portion 203 may be disposed between the first ring 204 and the wellbore
tubular 220 in a small gap therebetween. Similarly, the binder portion
203 may also be disposed between the second ring 206 and/or the rib 208
and the wellbore tubular 220 in a small gap therebetween. In an
embodiment, the binder portion 203 may bond to the wellbore tubular 220
over the contact area between the binder portion 203 and the wellbore
tubular 220, and the binder portion 203 may bond to the body portion 202
over the contact area between the binder portion 203 and the body portion
202. Once formed, the binder portion 220 may also retain the body portion
202 on the wellbore tubular 220 through the formation of a physical
retaining structure disposed within the body portion 202 in chambers 230,
232. For example, the binder portion 203 may provide a physical retaining
force through the interaction of the outer edge of the binder portion 203
with the inner edge of the body portion 202 at the interfaces 240, 242
when the body portion experiences a longitudinal force directed from the
end 222 to the end 224. Similarly, the binder portion 203 may provide a
physical retaining force through the interaction of the outer edge of the
binder portion 203 with the inner edge of the body portion 202 at the
interfaces 244, 246 when the body portion experiences a longitudinal
force directed from the end 224 to the end 222.

[0041] The binder portion 203 may comprise any material capable of being
disposed within the chambers 230, 232 and forming the chemical and/or
mechanical bond to retain the body portion 202 in position relative to
the wellbore tubular 220. In an embodiment, the binder portion 203 may
include, but is not limited to, a composite, a resin, an epoxy, or any
combination thereof. The binder portion 203 may be disposed and/or bonded
to the wellbore tubular 220 and/or body portion 202 using any known
techniques for applying the desired material. For example, an injection
method, molding, curing, or any combination thereof may be used to apply
the binder portion 203 within the chambers 230, 232, as discussed in more
detail herein. The binder portion 203 may generally be disposed within
the chambers 230, 232 so as to substantially fill the chambers 230, 232.

[0042] The binder portion 203 of the limit collar 200 may comprise one or
more composite materials. The matrix material of the binder portion 203
may comprise a resin component, which may be used to form a resin matrix.
Suitable resin matrix materials that may be used in the composite
materials described herein may include, but are not limited to, any of
the resin materials, two-component resin compositions, and/or
combinations thereof described herein for use with the body portion 202.
The matrix material of the binder portion 203 may or may not comprise any
fibers or particulates such as those described with respect to the body
portion above, which may include particulates and/or chopped fibers. The
strength of the interface between the fibers, chopped fibers, and/or
particulates and the matrix material may be modified or enhanced through
the use of a surface coating agent including any of those described
herein. In an embodiment, a matrix material or any components thereof in
the body portion may be the same or different as the matrix material or
any components thereof in the binder portion 203.

[0043] In an embodiment, the binder portion 203 may comprise a ceramic
based resin including, but not limited to, the types disclosed in U.S.
Patent Application Publication Nos. US 2005/0224123 A1, entitled
"Integral Centraliser" and published on Oct. 13, 2005, and US
2007/0131414 A1, entitled "Method for Making Centralizers for
Centralising a Tight Fitting Casing in a Borehole" and published on Jun.
14, 2007, both of which are incorporated herein by reference in their
entirety. For example, in some embodiments, the resin material may
include bonding agents such as an adhesive or other curable components.
In some embodiments, components to be mixed with the resin material may
include a hardener, an accelerator, or a curing initiator. Further, in
some embodiments, a ceramic based resin composite material may comprise a
catalyst to initiate curing of the ceramic based resin composite
material. The catalyst may be thermally activated. Alternatively, the
mixed materials of the composite material may be chemically activated by
a curing initiator. More specifically, in some embodiments, the composite
material of the binder portion 203 may comprise a curable resin and
ceramic particulate filler materials.

[0044] The length 250 of the limit collar 200 and/or the length 252, 254
of one or more of the binder portions 203 may be chosen to provide a
sufficient retaining force for the limit collar 200. When the binder
portion 203 is disposed and/or bonded to the wellbore tubular 220, a
mechanical and/or chemical bond may be formed over the contact surface.
Accordingly, the length 250, length 252, and/or length 254 may be chosen
to provide a surface area over which the mechanical and/or chemical bond
can act to provide a total retaining force at or above a desired level.
In an embodiment, the total retaining force may meet or exceed a load
rating or specification for the limit collar 200. The surface area over
which the mechanical and/or chemical bond can act may be determined at
least in part based on the length 250, length 252, and/or length 254 and
the diameter of the wellbore tubular 220 at the contact surface. Any
surface treatments of the wellbore tubular 220 and/or the inner surface
of the body portion 202 in contact with the binder portion 203 may be
considered when determining the length 250, length 252, and/or length
254.

[0045] In an embodiment, three or more chambers may be provided in which
the binder portion may be disposed to provide a desired retaining force
for the limit collar 200 on the wellbore tubular 220. As shown in FIG. 3,
a plurality of ribs 310, 312 may be provided along with the first ring
204 and the second ring 206 to provide for a plurality of chambers 302,
304, 306. As described above, the chambers 302, 304, 306 may be formed by
the one or more recesses 314, 316, 318, the outer surface of the wellbore
tubular 220, and the corresponding inner upsets (e.g., first ring 204,
second ring 206, rib 310, and/or rib 312). For example, chamber 302 may
be formed by the inner surface of the body portion 202 within the recess
314, the outer surface of the wellbore tubular 220, and the corresponding
inner edges of the second ring 206 and the rib 310. Chamber 304 may be
formed by the inner surface of the body portion 202 within the recess
316, the outer surface of the wellbore tubular 220, and the corresponding
inner edges of the rib 310 and the rib 312. Similarly, chamber 306 may be
formed by the inner surface of the body portion 202 within the recess
318, the outer surface of the wellbore tubular 220, and the corresponding
inner edges of the rib 312 and the first ring 204. One or more holes 210
may be disposed in one or more of the first ring 204, second ring 206,
rib 310, and/or rib 312. One or more screws 350 may be disposed within
one of the one or more holes and may engage the wellbore tubular 220. One
or more channels as described above may be provided in one or more of the
ribs when a plurality of ribs is present. While not shown in FIG. 3, one
or more holes may be disposed in the body portion adjacent to the
chambers 302, 304, 306 to provide fluid communication between two or more
of the chambers 302, 304, 306.

[0046] While FIG. 3 illustrates two ribs 310, 312 and three corresponding
chambers 302, 304, 306, any number of ribs and chambers may be provided.
In an embodiment, the body portion may comprise one rib, two ribs, three
ribs, four ribs, five ribs, six ribs, seven ribs, eight ribs, nine ribs,
or alternatively ten ribs. In an embodiment, the limit collar 200 may
comprise two chambers, three chambers, 4 chambers, five chambers, six
chambers, seven chambers, eight chambers, nine chambers, ten chambers, or
alternatively ten chambers. When the limit collar 200 comprises a
plurality of ribs, the ribs may be evenly spaced along the longitudinal
length of the limit collar between the first ring 204 and the second ring
206, or the ribs may be unevenly spaced along the longitudinal length of
the limit collar between the first ring 204 and the second ring 206.
Further, the longitudinal length of each rib may vary, the number and
configuration of any channels may vary, and the number and configuration
of the holes 210 may vary from rib to rib.

[0047] With reference to FIG. 2A and FIG. 2B, the limit collar 200 may be
disposed on the wellbore tubular 220 using a variety of methods. In an
embodiment, the method used to dispose the limit collar 200 on the
wellbore tubular 220 may depend, at least in part, on the material or
materials used to form the body portion 202 and the binder portion 203.
The body portion 202 may be formed as described herein and then be
disposed on or about the wellbore tubular 220. In an embodiment, the body
portion may be passed over an end of the wellbore tubular 220, for
example before the wellbore tubular 220 is configured into a wellbore
tubular string. One or more set screws may be disposed within one or more
holes 210. The set screws may engage the wellbore tubular 220 surface to
retain the body portion 202 in position on the wellbore tubular 220. One
or more of the holes 210 may be left open without a set screw for
applying the binder portion 203 to the body portion 202.

[0048] In an embodiment, the wellbore tubular may first be treated to
prepare the surface for receiving the body portion 202. In this process,
the outer surface of the wellbore tubular 220 may be optionally prepared
using any known technique to clean and/or provide a suitable surface for
bonding the binder portion 203 material to the wellbore tubular 220. In
an embodiment, the surface of the wellbore tubular 220 may be metallic.
The attachment surface may be prepared by sanding, sand blasting, bead
blasting, chemically treating the surface, heat treating the surface, or
any other treatment process to produce a clean surface for applying the
binder portion to the wellbore tubular 220. In an embodiment, the
preparation process may result in the formation of one or more surface
features such as corrugation, stippling, or otherwise roughening of the
surface, on a microscopic or macroscopic scale, to provide an increased
surface area and suitable surface features to improve bonding between the
surface and the binder portion 203 material or materials.

[0049] The binder portion 203 may then be applied to the body portion 202
to form the limit collar 200. The binder portion 203 may be applied using
a variety of methods to allow the binder portion 203 to engage, couple,
and/or bond to the wellbore tubular 220 and/or the body portion 202. When
the binder portion 203 comprises a composite, a ceramic, a resin, and/or
an epoxy, the material or materials forming the binder portion 203 may be
fluids that may be provided prior to an application process such as
injection and/or molding. In an embodiment, the binder portion 203
material or materials may be provided as separate two-part raw material
components for admixing during injection and/or molding and whereby the
whole can be reacted. The reaction may be catalytically controlled such
that the various components in the separated two parts of the composite
material do not react until they are brought together under suitable
injection and/or molding conditions. Thus, one part of the two-part raw
material may include an activator, initiator, and/or catalytic component
required to promote, initiate, and/or facilitate the reaction of the
whole mixed composition. In some embodiments, the appropriate balance of
components may be achieved by the use of pre-calibrated mixing and dosing
equipment.

[0050] In an embodiment, the binder portion 203 may be applied to the body
portion 202 through one or more of the holes 210. The body portion 202
may be retained in position over the optionally prepared wellbore tubular
220 surface through the use of the set screws. A connection mechanism may
be used to provide the binder portion 203 material or materials to one or
more of the holes 210 in the body portion 202. The binder portion 203
material or materials described herein may then be introduced into the
one or more holes 210. The binder portion 203 material or materials may
flow through the one or more holes 210 into the chambers 230, 232 and
harden and/or set to form the binder portion 203. The binder portion 203
material or materials may be introduced into one chamber and allowed to
flow through one or more of the channels 214 into one or more additional
chambers. In an embodiment, the hole or holes 210 into which the binder
portion 203 material or materials are introduced may correspond to a rib
and/or a channel 214. For example, one or more of the holes 210 into
which the binder portion 203 material or materials are introduced may
correspond to the hole 210 in communication with the channel 214 to allow
the binder portion 203 material or materials to flow into chambers 230,
232. The binder portion 203 material or materials may flow from the hole
into the space between the inner surface of the rib 208 and the outer
surface of the wellbore tubular 220 into one or more chambers. In an
embodiment, the binder portion 203 material or materials may be
introduced into a plurality of holes 210 simultaneously or sequentially
to introduce the binder portion material or materials into the chambers.
In an embodiment, multiple portions of a multi-part resin may be
introduced into separate holes and allowed to mix within one or more of
the chambers. In an embodiment, different binder portion materials may be
introduced into different chambers to produce a limit collar 200 with
different binder portion 203 material profiles.

[0051] While the first ring 204, the second ring 206, and/or one or more
ribs may be configured to contact or nearly contact the surface of the
wellbore tubular 220, a small gap may be present between the first ring
204, the second ring 206, and/or one or more ribs and the outer surface
of the wellbore tubular 220. As the binder portion 203 is introduced into
the body portion 202, the binder portion 203 may be introduced to
substantially file the chambers, and in an embodiment, the binder portion
may be introduced until the binder portion 203 material or materials flow
out through the small gaps from the first ring 204 and/or the second ring
206. In an embodiment, an adhesive layer such as a layer of adhesive tape
or double sided adhesive tape may be applied between the first ring 204
and/or the second ring 206 to substantially prevent any fluid
communication between the chambers 230, 232 and the exterior of the limit
collar 200. In this way, the binder portion 203 may extend between the
inner surface of the first ring 204, second ring 206, and/or one or more
ribs and the outer surface of the wellbore tubular 220.

[0052] Once introduced into one or more of the chambers, the limit
component 202 material or materials may be allowed to harden and/or set.
In an embodiment, the one or more holes into which the binder portion 203
material or materials are introduced may receive a set screw to seal the
one or more holes 210 as the binder portion hardens and/or sets. In an
embodiment, heat may be applied to thermally activate a thermally setting
resin, or a sufficient amount of time may be provided for the curing of
the binder portion 203 material or materials. In an embodiment, a
plurality of binder portion 203 materials may be used with multiple
injection periods and/or multiple holes 210 to produce a desired limit
collar 200 structure and/or composition.

[0053] As shown in FIG. 4, a wellbore tubular 220 comprising a limit
collar 404, 406 retaining a component 402 may be provided using one or
more of the limit collars described herein. In an embodiment, the
component 402 retained on the wellbore tubular 220 may comprise any
number of components including, but not limited to, a centralizer, a
packer, a cement basket, various cement assurance tools, testing tools,
and the like. In an embodiment, the component 402 may comprise a
centralizer of the type disclosed in U.S. patent application Ser. No.
13/013,259, entitled "Composite Bow Centralizer" by Lively et al. and
filed on Jan. 25, 2011, which is incorporated herein by reference in its
entirety. The component 402 may be slidingly engaged with the wellbore
tubular 220 to allow for movement relative to the wellbore tubular 220.
The component 402 may be retained on the wellbore tubular 220 by forming
a limit collar 404 using any of the methods described herein, followed by
disposing one or more components 402 about the wellbore tubular 220. The
component 402 may be configured to move relative to the wellbore tubular
220 while being retained when the component 402 engages the limit collar
404. One or more additional limit collars 406 may be formed using any of
the methods described herein, thereby retaining the component 402 on the
wellbore tubular 220 between the two limit collars 404, 406. Once formed,
the wellbore tubular 220 comprising at least one limit collar 404 and the
component 402 to be retained on the wellbore tubular 220 may be placed
within a wellbore. The wellbore tubular 220 ma then be conveyed within
the wellbore, and the first component may be retained on the wellbore
tubular due to the engagement of the first component with the limit
collar.

[0054] In an embodiment, a plurality of components retained by a plurality
of limit collars according to the present disclosure may be used with one
or more wellbore tubular sections. A wellbore tubular string refers to a
plurality of wellbore tubular sections connected together for conveyance
within the wellbore. For example, the wellbore tubular string may
comprise a casing string conveyed within the wellbore for cementing. The
wellbore casing string may pass through the wellbore prior to the first
casing string being cemented, or the casing string may pass through one
or more casing strings that have been cemented in place within the
wellbore. As another example, the wellbore tubular string may comprise a
production string conveyed within the wellbore to produce one or more
hydrocarbons from the wellbore and/or inject one or more injection fluids
into the wellbore. In an embodiment, the wellbore tubular string may
comprise premium connections, flush connections, and/or nearly flush
connections. A plurality of limit collars as described herein may be used
on the wellbore tubular string to maintain one or more components (e.g.,
a centralizer or a plurality of centralizers) on the wellbore tubular
string as it is conveyed within the wellbore. The number of limit collars
and their respective spacing along a wellbore tubular string may be
determined based on a number of considerations including the properties
of each component being retained on the wellbore tubular, the properties
of the wellbore tubular (e.g., the sizing, the weight, etc.), and the
properties of the wellbore through which the wellbore tubular is passing
(e.g., the annular diameter, the tortuosity, the orientation of the
wellbore, etc.). In an embodiment, a wellbore design program may be used
to determine the number and type of the limit collars and components
retained on the wellbore tubular string based on the various inputs as
described herein. The number and spacing of the limit collars and
components retained by the limit collars along the wellbore tubular may
vary along the length of the wellbore tubular based on the expected
conditions within the wellbore.

[0055] As described herein, the limit collar may be used with a wellbore
tubular disposed within a wellbore in a subterranean formation. The limit
collar described herein may be formed from non-metallic components to
help prevent corrosion of the wellbore tubular. When metallic limit
collar components of different compositions are provided within the
wellbore and in contact with the wellbore tubular, a galvanic cell may be
established in the presence of an electrolytic solution, resulting in
corrosion of the limit collar and/or the wellbore tubular. As the
metallic components corrode and/or degrade, unwanted metallic components
may be deposited within the wellbore. By providing a non-metallic limit
collar, the corrosion of the wellbore tubular may be prevented. Further,
the use of the body portion may provide the desired strength of the limit
collar through the use of a composite material while the use of the
binder portion may provide the desired retaining force of the limit
collar on the wellbore tubular. The limit collar described herein may
also be quickly and easily installed at the well site without the need
for metal working equipment.

[0056] At least one embodiment is disclosed and variations, combinations,
and/or modifications of the embodiment(s) and/or features of the
embodiment(s) made by a person having ordinary skill in the art are
within the scope of the disclosure. Alternative embodiments that result
from combining, integrating, and/or omitting features of the
embodiment(s) are also within the scope of the disclosure. Where
numerical ranges or limitations are expressly stated, such express ranges
or limitations should be understood to include iterative ranges or
limitations of like magnitude falling within the expressly stated ranges
or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.;
greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever
a numerical range with a lower limit, Rl, and an upper limit,
Ru, is disclosed, any number falling within the range is
specifically disclosed. In particular, the following numbers within the
range are specifically disclosed: R=Rl+k*(Ru-Rl), wherein
k is a variable ranging from 1 percent to 100 percent with a 1 percent
increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5
percent, . . . , 50 percent, 51 percent, 52 percent, . . . , 95 percent,
96 percent, 97 percent, 98 percent, 99 percent, or 100 percent. Moreover,
any numerical range defined by two R numbers as defined in the above is
also specifically disclosed. Use of the term "optionally" with respect to
any element of a claim means that the element is required, or
alternatively, the element is not required, both alternatives being
within the scope of the claim. Use of broader terms such as comprises,
includes, and having should be understood to provide support for narrower
terms such as consisting of, consisting essentially of, and comprised
substantially of. Accordingly, the scope of protection is not limited by
the description set out above but is defined by the claims that follow,
that scope including all equivalents of the subject matter of the claims.
Each and every claim is incorporated as further disclosure into the
specification and the claims are embodiment(s) of the present invention.

Patent applications by David Levie, Kastanienbaum CH

Patent applications by HALLIBURTON ENERGY SERVICES, INC.

Patent applications in class Providing support for well part (e.g., hanger or anchor)

Patent applications in all subclasses Providing support for well part (e.g., hanger or anchor)